Compressed air energy storage power station coordination control method

Abstract

The invention relates to the technical field of compressed air energy storage power stations, and discloses a compressed air energy storage power station coordination control method, which is based on a unit coordination control system consisting of a turbine and a heat exchanger, and comprises the following steps: acquiring a unit load instruction of the unit coordination control system; a coordination control model is constructed, energy balance between the heat exchanger and the turbine is coordinated through the coordination control model according to the unit load instruction, the actual operation condition and operation mode of the unit and the dynamic characteristics of the turbine and the heat exchanger, and load and main gas temperature combined control is carried out; and the subsystems of the heat exchanger and the turbine are respectively controlled according to instructions output by the main control system of the heat exchanger and the turbine. The adjusting capacity of the compressed air energy storage power station in the power grid is improved, efficient and stable operation of the power station can be achieved under different power grid operation conditions, and particularly under the condition that the power grid load fluctuation is large, it is guaranteed that the power station can adjust power output in time, and the frequency and load balance of the power grid is guaranteed.

Description

Technical Field

[0001] The present invention relates to the technical field of compressed gas energy storage power stations, and in particular to a coordinated control method for compressed gas energy storage power stations. Background Art

[0002] New energy storage technologies, particularly compressed air energy storage (CAES), have become a crucial pillar in building modern power systems. As the world strives to achieve carbon peak and carbon neutrality, energy storage is viewed as a key technology for achieving clean energy transitions and improving the flexibility and stability of power systems. Especially with the increasing penetration of large-scale renewable energy sources (such as wind and solar), effectively balancing the operational stability of energy storage power plants with grid demand has become a key issue in driving energy transition.

[0003] Compressed air energy storage (CAESS) power plants, a representative example of large-scale energy storage technology, offer significant regulatory capacity and emergency reserve capabilities. However, as power plants grow in size and complexity, achieving efficient, safe, and economical coordinated control has become a bottleneck in technological development. Research on coordinated control methods for CAESS can effectively improve the operational efficiency of energy storage systems and support grid stability and optimized dispatch.

[0004] Currently, the control technology for large generator sets primarily relies on analog control, which focuses on automated equipment management, such as load, pressure, temperature, and flow rate adjustments. Although traditional analog control methods can ensure stable operation of generator sets under certain operating conditions, as generator set capacity increases, existing control methods face the following shortcomings and challenges:

[0005] 1. Insufficient control accuracy and response speed: Existing control systems primarily rely on a combination of coarse and fine adjustments, using feedback and feedforward mechanisms for regulation. However, under rapidly changing load demands and complex external disturbances, the response speed and accuracy of existing systems are insufficient to meet the requirements of compressed gas energy storage power plants. This can lead to short-term overreaction or delayed response, impacting grid stability.

[0006] 2. Poor adaptability to grid load changes: Current control methods primarily focus on coordinating individual devices and fail to effectively account for the dynamic nature of grid load changes. With grid load fluctuations, particularly the instability of renewable energy output, traditional coordinated control methods lack the flexibility and adaptability to dynamically adjust the balance between unit output and load demand in real time.

[0007] 3. Insufficient integration of AGC and primary frequency regulation: Although automatic generation control (AGC) and primary frequency regulation were introduced to enhance the system's regulation capabilities, existing coordinated control systems still face challenges in effectively integrating AGC with the coordinated control of energy storage plants. AGC systems typically rely on grid frequency fluctuations to regulate generator power. However, the energy storage and release characteristics of compressed gas energy storage plants can lead to inflexible or delayed AGC control, impacting the efficient operation of energy storage plants.

[0008] 4. Inadequate system stability and disturbance suppression capabilities: Traditional coordinated control systems have limited stability and disturbance suppression capabilities in their regulation strategies when faced with external disturbances. In large-scale energy storage systems, external disturbances (such as sudden load changes in the grid or equipment failures) can lead to system instability or frequent fluctuations, impacting the economic viability and safety of energy storage plants.

[0009] 5. Inadequate control system integration and optimization: Existing coordinated control methods mostly focus on local control and optimal scheduling of individual units, but lack overall optimization and integrated coordination for the entire power plant system. In large-scale energy storage power plants, optimizing the overall plant's operating efficiency while ensuring safety and economic efficiency is a key technical challenge.

[0010] Therefore, studying an efficient coordinated control method that can address the shortcomings of the above-mentioned existing technologies and improve the response speed, regulation accuracy and adaptability of energy storage power stations to the power grid has become a key task in current technological development. Summary of the Invention

[0011] The present invention provides a coordinated control method for a compressed air energy storage power station, which improves the regulation capability of the compressed air energy storage power station in the power grid. It can achieve efficient and stable operation of the power station under different power grid operating conditions, especially when the power grid load fluctuates greatly, ensuring that the power station can adjust the power output in time and ensure the frequency and load balance of the power grid.

[0012] The present invention provides a coordinated control method for a compressed gas energy storage power station, based on a coordinated control system of a unit consisting of a turbine and a heat exchanger, comprising:

[0013] Obtaining a unit load instruction of the unit coordinated control system; wherein the unit load value instruction is an actual unit load instruction obtained through amplitude and rate limitation through calculation based on an AGC instruction or an operator instruction;

[0014] Constructing a coordinated control model to coordinate the energy balance between the heat exchanger and the turbine based on the unit load command, the actual operating conditions and operating mode of the unit, and the dynamic characteristics of the turbine and the heat exchanger, and to perform joint control of the load and main gas temperature;

[0015] According to the instructions output by the main control system of the heat exchanger and turbine, the subsystems of the heat exchanger and turbine are controlled respectively.

[0016] Furthermore, the step of obtaining the unit load instruction of the unit coordinated control system includes:

[0017] First, determine whether the AGC is engaged. If so, the AGC command enters the coordinated control model. If not, the CCS load command enters and is compared with the upper and lower load limits to obtain the H / L signal.

[0018] Determine whether the primary frequency modulation is enabled. If enabled, the speed difference is processed by the function F(x). If not enabled, the input is 0.

[0019] The unit load command is obtained by adding the AGC command or CCS load command result, the speed difference processing result and the RL rate.

[0020] Furthermore, in the step of constructing a coordinated control model, based on the unit load instruction, the actual operating conditions and operating mode of the unit, and the dynamic characteristics of the turbine and heat exchanger, the coordinated control model is used to coordinate the energy balance between the heat exchanger and the turbine to perform joint control of the load and main gas temperature. The coordinated control model includes a fast load reduction RB loop, specifically:

[0021] The load command enters the unit coordinated control system. When there is no RB, the load deviation is obtained through the rate. After being processed by the pre-addition and subtraction common logic, the pre-addition and subtraction of high-temperature circulating water and pre-addition and subtraction of heat exchange are output. When there is RB, the rate of the RB target load is calculated with the load deviation when there is no RB. After being processed by PID and function F(x), the sum is added and sent to the turbine main control.

[0022] The air temperature is set to obtain the temperature deviation through the rate, which enters the PID adjustment and then enters the heat exchanger main control;

[0023] The main control output of the heat exchanger is divided into three routes. Four high-pressure heat exchanger outlet water regulating valves are controlled via F1(x), two medium-pressure heat exchanger outlet water regulating valves are controlled via F2(x), and three low-pressure heat exchanger outlet water regulating valves are controlled via F3(x) to achieve stable operation and parameter adjustment of the unit coordinated control system.

[0024] Furthermore, the coordinated control model includes a load increase / decrease feedforward loop, which performs correction according to load deviation, main gas temperature deviation, and load increase rate, specifically:

[0025] The unit target load is subtracted from the actual load instruction, and the difference is multiplied by the main gas temperature deviation and the unit load change rate processed by the function. At the same time, the absolute value of the difference is taken and processed by the function, and multiplied by the unit load change rate after the function operation. Finally, the pre-addition and subtraction public instruction is obtained to achieve control and adjustment of the unit operating status.

[0026] Furthermore, in the step of constructing a coordinated control model, based on the unit load command, the actual operating conditions and operating mode of the unit, and the dynamic characteristics of the turbine and heat exchanger, the energy balance between the heat exchanger and the turbine is coordinated by the coordinated control model to perform joint control of the load and main gas temperature. Coordinating the energy balance between the heat exchanger and the turbine includes four methods, each of which is determined according to the turbine main control circuit and the heat exchanger main control circuit, specifically:

[0027] (1) Coordinated control method

[0028] When both the heat exchanger master control and the turbine master control are in automatic mode, the unit coordinated control system automatically switches to coordinated control mode. In this mode, the unit load is automatically controlled by the turbine master control, and the main gas temperature is automatically controlled by the heat exchanger master control.

[0029] (2) Heat exchanger following mode

[0030] When the heat exchanger master control is in automatic mode and the turbine master control is in manual mode, the unit coordinated control system automatically switches to heat exchanger tracking mode. In this mode, the unit load is manually changed by the operator through the turbine master control, while the main air temperature is automatically adjusted by the heat exchanger master control. That is, the heat exchanger automatically adjusts the main air temperature, while the turbine manually adjusts the unit load.

[0031] (3) Turbine following mode

[0032] When the heat exchanger master control is in manual mode and the turbine master control is in automatic mode, the unit coordinated control system automatically switches to turbine tracking mode. In this mode, the unit load is automatically controlled by the operator through the turbine master control, while the heat exchanger master control manually controls the main gas temperature.

[0033] (4) Manual method

[0034] When the heat exchanger master control and turbine master control are both in manual state, the control mode of the unit coordinated control system will automatically switch to basic mode; in this mode, the unit's load and main air temperature control are manually controlled by the heat exchanger master control and turbine master control.

[0035] Furthermore, the subsystem for controlling the heat exchanger and turbine includes high-temperature circulating water, a heat exchanger, and DEH.

[0036] The beneficial effects of the present invention are:

[0037] The proposed coordinated control method for compressed air energy storage power plants, based on a 300MW compressed air energy storage power plant project, is applicable to other large-scale compressed air energy storage power plants. It effectively improves the operating efficiency of the energy release system and supports grid stability and optimized scheduling. Compared with traditional power plant coordinated control methods, this invention, through the design of a coordinated control system, enables automated operation of units in different load ranges, significantly reducing manual operations, enhancing the system's automation and intelligence, ensuring system stability, and improving control accuracy and response speed. Furthermore, the system can autonomously complete energy release control, reducing the burden on operators. More importantly, the system not only meets the requirements for safe, stable, and economical unit operation, but also rapidly responds to grid scheduling requirements, enhancing the grid's regulation capabilities. This method also provides data support for the analog control acceptance standards for large-scale compressed air energy storage power plants, contributing to the supplementation and improvement of industry standards and promoting technological development. Finally, the optimized control method reduces operating costs, improves the economic benefits of the power plant, and ensures the stability, efficiency, and safety of compressed air energy release. BRIEF DESCRIPTION OF THE DRAWINGS

[0038] Figure 1 Schematic diagram of the flow of the coordinated control method of the compressed gas energy storage power station of the present invention.

[0039] Figure 2 Schematic diagram of the fast load reduction RB circuit in the present invention.

[0040] Figure 3 Schematic diagram of the AGC and primary frequency modulation control loop in the present invention.

[0041] Figure 4 Schematic diagram of the load lifting feedforward loop in the present invention.

[0042] The purpose, features and advantages of the present invention will be further described with reference to the accompanying drawings and in conjunction with the embodiments. DETAILED DESCRIPTION

[0043] It should be understood that the specific embodiments described herein are only used to explain the present invention and are not intended to limit the present invention.

[0044] This invention proposes a technical solution for the coordinated control of large-scale non-supplementary-fired compressed air energy storage power stations. First, through extensive research, the main technical parameters of the main and auxiliary machines of the compressed air energy storage power station, the process flow of each subsystem and the characteristics of the operating mode were mastered. In addition, the role and impact of the compressed air energy storage power station on the power grid under different operating conditions were deeply analyzed, especially in terms of application requirements such as regulating the grid frequency and balancing load fluctuations. Subsequently, combined with the research results, by consulting relevant journals, books, national standards and research papers, the existing technology was analyzed, and a theoretical model of the coordinated control method suitable for compressed air energy storage power stations was constructed, providing a solid theoretical foundation for the subsequent development of control strategies.

[0045] On this basis, the present invention designs a new coordinated control system, which aims to improve the regulation capability of the compressed air energy storage power station in the power grid. It can achieve efficient and stable operation of the power station under different power grid operating conditions, especially when the power grid load fluctuates greatly, to ensure that the power station can adjust the power output in time and ensure the frequency and load balance of the power grid. According to the characteristics of the compressed air energy storage power station, the coordinated control system constructs a control logic framework for the turbine generator subsystem, the heat storage and exchange subsystem and the gas storage reservoir subsystem, and optimizes the control strategy through data analysis. The system will ensure the coordination of energy flow between the subsystems through indirect or direct energy balance control to improve the stability, accuracy and speed of the system and reduce the burden on operators. Finally, in combination with the regulations, unit performance and operating procedures of the local power grid, a specific control scheme was formulated, and the configuration of the control logic was realized through DCS or PLC to ensure the accurate execution of the control strategy and the efficient operation of the power station.

[0046] This technical solution not only provides comprehensive optimization of the compressed air energy storage power station, but also realizes the coordinated interconnection between the power station and the power grid, which helps to improve the stability of the power grid, the utilization rate of renewable energy and the overall operating efficiency of the power system.

[0047] like Figure 1 As shown, the present invention provides a method for coordinated control of a compressed gas energy storage power station, based on a coordinated control system of a unit composed of a turbine and a heat exchanger, comprising the following steps:

[0048] S1. Obtaining a unit load instruction of the unit coordinated control system; wherein the unit load value instruction is an actual unit load instruction obtained through amplitude and rate limitation through calculation processing based on an AGC instruction or an operator instruction.

[0049] Prior to this, it is necessary to collect and organize relevant information, mainly including: design drawings of the design institute, information on major equipment, etc., to determine the process and technical parameters of the equipment involved and the operating data analysis of the participating units.

[0050] Automatic Generation Control (AGC) commands and operator commands provide target unit load values. The algorithm performs mathematical calculations based on these inputs to generate acceptable actual load commands. In other words, the system evaluates whether these commands are reasonable given the current operating conditions or whether further adjustments are needed.

[0051] After the system calculates the amplitude limit and rate limit, the calculation process will check whether the amplitude of the instruction exceeds the set limit range and adjust it to an allowable safety range.

[0052] S2. Construct a coordinated control model. Based on the load instruction of the unit, the actual operating conditions and operating mode of the unit, and the dynamic characteristics of the turbine and heat exchanger, coordinate the energy balance between the heat exchanger and the turbine through the coordinated control model, and perform joint control of the load and main gas temperature, so that the unit can adapt to the load demand and operate stably.

[0053] The coordinated control system for the compressed air energy storage power station was determined. The operating characteristics of the operating units were analyzed, and various control logic algorithms were developed. Four energy release modes were designed for the compressed air energy storage power station, each based on the turbine master control and heat exchanger master control circuits. The coordinated control mode offers the highest level of automated load control. Load commands are sent simultaneously to the heat exchanger master control and the turbine master control, minimizing power deviations.

[0054] (1) Coordinated Control System (CCS)

[0055] When both the heat exchanger master control and the turbine master control are in automatic mode, the unit coordinated control system automatically switches to coordinated control mode. In this mode, the unit load is automatically controlled by the turbine master control, and the main gas temperature is automatically controlled by the heat exchanger master control.

[0056] (2) Heat exchanger follow mode (HF—Heat follow)

[0057] When the heat exchanger master control is in automatic mode and the turbine master control is in manual mode, the unit coordinated control system automatically switches to heat exchanger tracking mode. In this mode, the unit load is manually adjusted by the operator using the turbine master control, while the main air temperature is automatically adjusted by the heat exchanger master control. In other words, the heat exchanger automatically adjusts the main air temperature, while the turbine manually adjusts the unit load.

[0058] (3) Turbine follow mode (TF—Turbine follow)

[0059] When the heat exchanger master control is in manual mode and the turbine master control is in automatic mode, the unit coordinated control system automatically switches to turbine tracking mode. In this mode, the unit load is automatically controlled by the operator through the turbine master control, while the heat exchanger master control manually controls the main gas temperature.

[0060] (4) Manual

[0061] When both the heat exchanger master control and the turbine master control are in manual mode, the unit coordinated control system automatically switches to basic mode. In this mode, the unit load and main air temperature are controlled manually by the heat exchanger master control and the turbine master control.

[0062] S3. According to the instructions output by the main control system of the heat exchanger and turbine, the subsystems of the heat exchanger and turbine (including high-temperature circulating water, heat exchanger, DEH, etc.) are controlled respectively, which is equivalent to the follow-up system of the main control system.

[0063] When multiple subsystems interact with each other in a large system, coordinated control of different subsystems is an important factor in improving efficiency, stability and reliability. Therefore, the above four methods all require coordination of subsystems.

[0064] In one embodiment, the coordinated control model includes a fast load reduction RB loop, such as Figure 2 As shown, specifically:

[0065] (1) When the load command enters the system, the load deviation is obtained through the rate when there is no RB. After the pre-addition and subtraction common logic processing, the pre-addition and subtraction of high-temperature circulating water and pre-addition and subtraction of heat exchange are output. When there is RB, the rate of the RB target load is calculated with the load deviation when there is no RB, and then the result is added after PID and function F(x) processing and then input into the turbine main control.

[0066] (2) The air temperature is set to the temperature deviation obtained by the rate, which enters the PID adjustment and then enters the heat exchanger main control;

[0067] (3) The main control output of the heat exchanger is divided into three routes. The four high-pressure heat exchanger outlet water regulating valves are controlled by F1(x), the two medium-pressure heat exchanger outlet water regulating valves are controlled by F2(x), and the three low-pressure heat exchanger outlet water regulating valves are controlled by F3(x) to achieve stable operation of the system and parameter adjustment.

[0068] In one embodiment, in the step of obtaining the unit load instruction of the unit coordinated control system, the coordinated control model is embedded in the AGC and primary frequency modulation control loop model, such as Figure 3 As shown, specifically including:

[0069] First, determine whether the AGC is engaged. If so, the AGC command enters the subsequent process, namely the coordinated control model. If not, the CCS load command enters and is compared with the upper and lower load limits to obtain the H / L signal. At the same time, determine whether the primary frequency modulation is engaged. If engaged, the speed difference is processed by the function F(x). If not, the input is 0. Finally, the relevant results of the AGC command or CCS load command, the relevant processing results of the speed difference, and the RL rate are added to obtain the unit load command, thereby achieving effective control and regulation of the unit load and ensuring that the unit operates in a safe, stable and required load range.

[0070] In one embodiment, due to the large heat storage and exchange inertia and nonlinearity of the energy release system, the coordinated control model also includes a load increase and decrease feedforward loop, which performs correction based on the load deviation, main gas temperature deviation, and load increase rate, specifically:

[0071] The unit target load is subtracted from the actual load instruction, and the difference is multiplied by the main gas temperature deviation and the unit load change rate processed by the function. At the same time, the absolute value of the difference is taken and processed by the function, and multiplied by the unit load change rate after the function operation. Finally, the pre-addition and subtraction public instruction is obtained to achieve control and adjustment of the unit operating status.

[0072] After the coordinated control model is constructed, the main parameter curves of each start and shutdown operation of the unit are retrieved, the required parameters in the control model are initially adjusted, the unit operation data is analyzed, the analog control strategy and parameter matching are adjusted multiple times, and the final coordinated control model and control parameters are finalized.

[0073] This invention constructs a control model for a coordinated control system and develops a standardized control logic framework to ensure that the system is highly automated and standardized. It also designs a control strategy that can support automatic operation of the unit under different load conditions, reduce manual operations, and improve monitoring efficiency and automation levels. It also provides data support for the subsequent formulation of analog control acceptance standards for large-scale compressed air energy storage power stations, supplementing and improving industry standards.

[0074] It should be noted that, in this document, the terms "comprises," "includes," or any other variations thereof are intended to encompass non-exclusive inclusion, such that a process, apparatus, article, or method comprising a series of elements includes not only those elements but also other elements not explicitly listed, or elements inherent to such process, apparatus, article, or method. In the absence of further limitations, an element defined by the phrase "comprising a ..." does not exclude the presence of other identical elements in the process, apparatus, article, or method comprising the element.

[0075] The above description is only a preferred embodiment of the present invention and does not limit the patent scope of the present invention. Any equivalent structure or equivalent process transformation made by using the contents of the present invention description and drawings, or directly or indirectly applied in other related technical fields, are also included in the patent protection scope of the present invention.

Claims

1. A method for coordinated control of a compressed gas energy storage power station, characterized in that: The coordinated control system for the turbine and heat exchanger unit includes: Obtaining a unit load instruction of the unit coordinated control system; wherein the unit load value instruction is an actual unit load instruction obtained through amplitude and rate limitation through calculation based on an AGC instruction or an operator instruction; Constructing a coordinated control model to coordinate the energy balance between the heat exchanger and the turbine based on the unit load command, the actual operating conditions and operating mode of the unit, and the dynamic characteristics of the turbine and the heat exchanger, and to perform joint control of the load and main gas temperature; According to the instructions output by the main control system of the heat exchanger and turbine, the subsystems of the heat exchanger and turbine are controlled respectively.

2. The coordinated control method of a compressed gas energy storage power station according to claim 1, characterized in that: The step of obtaining the unit load instruction of the unit coordinated control system includes: First, determine whether the AGC is engaged. If so, the AGC command enters the coordinated control model. If not, the CCS load command enters and is compared with the upper and lower load limits to obtain the H / L signal. Determine whether the primary frequency modulation is enabled. If enabled, the speed difference is processed by the function F(x). If not enabled, the input is 0. The unit load command is obtained by adding the AGC command or CCS load command result, the speed difference processing result and the RL rate.

3. The coordinated control method of a compressed gas energy storage power station according to claim 2, characterized in that: In the step of constructing a coordinated control model, based on the unit load instruction, the actual operating conditions and operating mode of the unit, and the dynamic characteristics of the turbine and the heat exchanger, coordinating the energy balance between the heat exchanger and the turbine through the coordinated control model to perform joint control of the load and the main gas temperature, the coordinated control model includes a fast load reduction RB loop, specifically: The load command enters the unit coordinated control system. When there is no RB, the load deviation is obtained through the rate. After being processed by the pre-addition and subtraction common logic, the pre-addition and subtraction of high-temperature circulating water and pre-addition and subtraction of heat exchange are output. When there is RB, the rate of the RB target load is calculated with the load deviation when there is no RB. After being processed by PID and function F(x), the sum is added and sent to the turbine main control. The air temperature is set to obtain the temperature deviation through the rate, which enters the PID adjustment and then enters the heat exchanger main control; The main control output of the heat exchanger is divided into three routes. Four high-pressure heat exchanger outlet water regulating valves are controlled via F1(x), two medium-pressure heat exchanger outlet water regulating valves are controlled via F2(x), and three low-pressure heat exchanger outlet water regulating valves are controlled via F3(x) to achieve stable operation and parameter adjustment of the unit coordinated control system.

4. The coordinated control method of a compressed gas energy storage power station according to claim 3, characterized in that: The coordinated control model includes a load feedforward loop, which performs correction based on load deviation, main gas temperature deviation, and load increase rate, specifically: The unit target load is subtracted from the actual load instruction, and the difference is multiplied by the main gas temperature deviation and the unit load change rate processed by the function. At the same time, the absolute value of the difference is taken and processed by the function, and multiplied by the unit load change rate after the function operation. Finally, the pre-addition and subtraction public instruction is obtained to achieve control and adjustment of the unit operating status.

5. The coordinated control method of a compressed gas energy storage power station according to claim 3, characterized in that: In the step of constructing a coordinated control model, coordinating the energy balance between the heat exchanger and the turbine using the coordinated control model based on the unit load command, the actual operating conditions and operating mode of the unit, and the dynamic characteristics of the turbine and heat exchanger to perform joint control of the load and main gas temperature, the energy balance between the heat exchanger and the turbine is coordinated in four ways, each of which is determined based on the turbine main control circuit and the heat exchanger main control circuit, specifically: (1) Coordinated control method When both the heat exchanger master control and the turbine master control are in automatic mode, the unit coordinated control system automatically switches to coordinated control mode. In this mode, the unit load is automatically controlled by the turbine master control, and the main gas temperature is automatically controlled by the heat exchanger master control. (2) Heat exchanger following mode When the heat exchanger master control is in automatic mode and the turbine master control is in manual mode, the unit coordinated control system automatically switches to heat exchanger tracking mode. In this mode, the unit load is manually changed by the operator through the turbine master control, while the main air temperature is automatically adjusted by the heat exchanger master control. That is, the heat exchanger automatically adjusts the main air temperature, while the turbine manually adjusts the unit load. (3) Turbine following mode When the heat exchanger master control is in manual mode and the turbine master control is in automatic mode, the unit coordinated control system automatically switches to turbine tracking mode. In this mode, the unit load is automatically controlled by the operator through the turbine master control, while the heat exchanger master control manually controls the main gas temperature. (4) Manual method When the heat exchanger master control and turbine master control are both in manual state, the control mode of the unit coordinated control system will automatically switch to basic mode; in this mode, the unit's load and main air temperature control are manually controlled by the heat exchanger master control and turbine master control.

6. The coordinated control method of a compressed gas energy storage power station according to claim 1, characterized in that: The subsystem for controlling the heat exchanger and turbine includes high-temperature circulating water, a heat exchanger, and DEH.

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